3-dimensional scanner for downhole well integrity reconstruction in the hydrocarbon industry

ABSTRACT

The present disclosure describes methods and systems for downhole well integrity reconstruction in a hydrocarbon reservoir. One in-situ 3-dimensional (3D) scanner includes a rangefinder configured to measure a distance between a subterranean location and a surface of a well; and a radiance sensor configured to generate a depth map of the subterranean location.

TECHNICAL FIELD

This disclosure relates to 3-Dimensional scanner for downhole wellintegrity reconstruction in the hydrocarbon industry.

BACKGROUND

In the hydrocarbon production industry, well integrity is an importantissue to be monitored and maintained. Example of well integrity issuescan include borehole rock instability issues, cased hole leaking orsplit casing issues, deteriorated casing section issues.

SUMMARY

The present disclosure describes methods and systems for discovering andfixing downhole well integrity issues. One method includes positioning,a laser head at a first subterranean location, wherein the laser head isattached to a tubular inside of a wellbore; directing, by the laserhead, a laser beam towards a leak on the wellbore; and sealing the leakusing the laser beam.

Another method for downhole well leak detection in a hydrocarbonreservoir, includes positioning, a 3-dimensional (3D) scanner at asubterranean location, wherein the 3D scanner is attached to a tubularinside of a wellbore; generating an image of the subterranean location;and transmitting the image to a surface of a well.

Yet another method for downhole well integrity reconstruction in ahydrocarbon reservoir includes: positioning, a 3-dimensional (3D)scanner at a subterranean location, wherein the 3D scanner is attachedto a tubular inside of a wellbore; generating an image of thesubterranean location; determining, based on the image, that a leak islocated at the subterranean location; positioning, a laser head at thesubterranean location, wherein the laser head is attached to thetubular; directing, by the laser head, a laser beam towards the leak;and sealing the leak using the laser beam.

One in-situ well integrity reconstruction device includes: a3-dimensional (3D) laser head; at least one hardware processor; and anon-transitory computer-readable storage medium coupled to the at leastone hardware processor and storing programming instructions forexecution by the at least one hardware processor, wherein theprogramming instructions, when executed, cause the in-situ wellintegrity reconstruction device to perform operations comprising:positioning, the 3D laser head at a first subterranean location, whereinthe 3D laser head is attached to a tubular inside of a wellbore; andwherein the 3D laser head is configured to: direct a laser beam towardsa leak at the first subterranean location; and seal the leak using thelaser beam.

One in-situ 3-dimensional (3D) laser head includes a reflector that isattached to a tubular inside of a wellbore; a focused lens; and whereinthe reflector is configured to reflect a laser beam towards the focusedlens; and the reflector and the focused lens are configured to berotatable to aim towards a leak on the wellbore.

One in-situ 3-dimensional (3D) scanner includes: a rangefinderconfigured to measure a distance between a subterranean location and asurface of a well; and a radiance sensor configured to generate a depthmap of the subterranean location.

The details of one or more implementations of the subject matter of thisdisclosure are set forth in the accompanying drawings and thedescription. Other features, aspects, and advantages of the subjectmatter will become apparent from the description, the drawings, and theclaims.

DESCRIPTION OF DRAWINGS

FIG. 1A is a schematic diagram that illustrates an example well systemhaving an open hole problem, according to an implementation.

FIG. 1B is a schematic diagram that illustrates an example well systemhaving a cased hole problem, according to an implementation.

FIG. 2 is a block diagram of an example 3D laser head used to performbottom hole well reconstruction, according to an implementation.

FIG. 3 is a block diagram of an example in-situ well integrityreconstruction device, according to an implementation.

FIG. 4 illustrates example effects of laser sealing, according to animplementation.

FIG. 5 illustrates an example laser sealing operation, according to animplementation.

FIG. 6 illustrates another example laser sealing operation, according toan implementation.

FIG. 7 illustrates yet another example laser sealing operation,according to respective implementations.

FIG. 8 is a block diagram of an example computer system used to providecomputational functionalities associated with described algorithms,methods, functions, processes, flows, and procedures, as described inthe instant disclosure, according to an implementation.

FIG. 9 is a schematic diagram that illustrates an example 3D imagingtool, according to an implementation.

Like reference numbers and designations in the various drawings indicatelike elements.

DETAILED DESCRIPTION

This disclosure generally describes methods and systems for discoveringand fixing downhole well integrity issues. Well integrity issues caninclude issues for cased holes and open holes. Cased hole problems canhappen due to casing decentralization, poor cement jobs, leaking packersor tubing, the existence of corrosive formations, and other reasons. Insome implementations, techniques for solving cased hole problems caninclude casing squeeze, sealant technologies, and mechanical casingrepairs. However, these techniques may have several drawbacks,including, for example, limited isolation and integrity, short life,high cost and time consumption, limited probability of operationalsuccess, and downhole restriction. Open hole problems can happen due tolost circulations (because of seepage, induced fractures, vugs, or otherreasons), over-gauge holes, rock reactivity, or other reasons. In someimplementations, techniques for solving open hole problems can includelost circulation material replacements, cement plugs, sealanttechnologies, and mechanical repairs. Similar to the techniquesdiscussed previously for cased hole problems, these techniques havelimited capabilities and do not provide an efficient solution.

In some cases, an integrated solution can be used to solve wellintegrity issues. For example, an in-situ well integrity reconstructiondevice can be used to perform well integrity monitoring andreconstruction operations in the subterranean region of a reservoir. Thein-situ well integrity reconstruction device can be attached to a drillpipe or other tubulars used to perform downhole operations. The in-situwell integrity reconstruction device can include a 3-dimensional (3D)imaging tool that scans the borehole for leaks, and a 3D laser head thatperforms the reconstruction operations. In some implementations, thein-situ well integrity reconstruction device can be remote controlled.For example, a surface device can receive the 3D images generated by the3D imaging tool and output to an operator or other devices. The operatorcan instruct the in-situ well integrity reconstruction device to performthe reconstruction operations. Alternatively or additionally, thein-situ well integrity reconstruction device can perform thereconstruction operations automatically. For example, the in-situ wellintegrity reconstruction device can analyze the 3D images and instructthe 3D laser head to perform the reconstruction operations. FIGS. 1-9and associated descriptions provide additional details of theseimplementations.

Using the in-situ well integrity reconstruction device to perform wellintegrity maintenance as described in this specification can provide oneor more advantages. For example, the welding and healing operations canbe performed during the drilling or other downhole operations, andtherefore provide an efficient solution for well integrity whilereducing operation interruptions. In addition, this approach provides areliable solution that can address both cased and open hole problems,including for example: fractures in downhole formation rocks, wash-outor undesired enlargements of the drilled wellbores, channels andde-bonding areas in the downhole sheaths of cement, and cracks indownhole tubulars such as well casings. Moreover, this approach does notdepend on isolations of specific hole section, inner diameterrestrictions, or injectivity, and, therefore, is more convenient tooperate. Furthermore, this approach is faster, less cumbersome, and canobtain a higher probability of success. The detection and visualizationcapabilities provide a view of the downhole troublesome zone during thecuring process, reveal the root cause of the degradation, and helpimproving the drilling Other advantages will be apparent to those ofordinary skill in the art.

FIG. 1A is a schematic diagram that illustrates an example well system100 having an open hole problem, according to an implementation. Theexample well system 100 can use an in-situ well integrity reconstructiondevice to direct a laser beam to a rock formation around a wellbore at asubterranean location to perform well integrity reconstructionoperations, as described. Examples of the well integrity reconstructionoperations include welding and healing the lost circulation zones,welding and sealing the fractured and unconsolidated rock zones, weldingcasing leaking and split zones, and rebuilding deteriorated casingsections. These operations can be performed during or after drilling.

The example well system 100 includes a wellbore 140 extending under theterranean surface 110. The wellbore 140 is drilled by a drill pipe 130that is connected to a drilling bit 136. The wellbore 140 is surroundedby casing strings 134 and tubular 132 that protect the wellbore 140 inthe downhole rock formation region 112.

The well system 100 includes an in-situ well integrity reconstructiondevice 190 that is installed on the drill pipe 130. The in-situ wellintegrity reconstruction device 190 includes a controller 170, a 3Dimaging tool 160, a 3D laser head 150, and a laser generator 174. Insome implementations, the drill pipe 130 can be replaced by othertubulars that are used to carry tools for downhole operations. Examplesof the other tubulars can include casing tubular and coiled tubing.

The 3D imaging tool 160 is configured to scan objects and points ofinterest downhole and generate 3D images. The areas of interest targetedby the 3D imaging tool 160 can include: fractures in downhole formationrocks, channels and de-bonding areas in the downhole sheaths of cement,cracks in downhole tubulars or well casings. For example, the 3D imagingtool 160 can be used to scan the wellbore 140 and the downhole reservoirrock region 114 surrounding the wellbore 140 to detect the rockfractures at location 122. A 3D imaging tool can also be referred to asa 3D scanner.

FIG. 9 is a schematic diagram that illustrates an example 3D imagingtool 160, according to an implementation. The 3D imaging tool 160includes a rangefinder 162, a radiance sensor 164, an endoscope 166, andan imaging processor 168. An 3D imaging tool may include additional,different, or fewer components as shown in FIG. 9, as appropriate.

The rangefinder 162 can be used to determine the distance to an object,the distance from a point, or both, in the wellbore 140 to the nearestsurface of the wellbore wall. This rangefinder 162 can detect, map, andscan points of interest downhole such as formation rock fractures andcaverns, casing leaks and tears, or cement de-bonding areas. In someimplementations, the rangefinder 162 can be a laser rangefinder, whichsends a laser pulse in a narrow beam towards the object and determinesthe range based on the time taken by the pulse to be reflected by thetarget and returned to the sender. The 3D imaging tool 160 also includesa radiance sensor 164. The radiance sensor 164 can be used to createdepth maps of points of interest downhole. The depth maps can be used toenhance the data obtained by the rangefinder 162 by removinginterferences such as fluids downhole.

The 3D imaging tool 160 can also include an endoscope 166. The endoscope166 can generate optical images of the points of interest downhole. Theimages generated by the endoscope 166 can be used to further enhance themeasurements made by the rangefinder 162 and the radiance sensor 164 byfiltering interferences from the measure results. In someimplementations, other imaging devices, for example, a downhole camera,can be used to generate optical images instead of the endoscope 166.

In some implementations, the 3D imaging tool 160 can also include one ormore imaging processors 168. The imaging processor 168 can be configuredto process the images generated by the endoscope 166. For example, theimaging processor 168 can image processing techniques that account forthe attenuation of light created downhole due to the presence ofdrilling fluids (mud) and improve the signal-to-noise ratio.

In some implementations, the 3D imaging tool 160, or components of the3D imaging tool 160 such as the rangefinder 162 and the radiance sensor164, can be implemented as an integrated part of the drill pipe 130.Such implementation can enable the 3D imaging tool 160 or the componentsthereof to withstand downhole conditions such as high pressure, hightemperature (HPHT), and exposure to sour gases or corrosion. The 3dimaging tool 160 or the components thereof can be integrated within themetal tubulars of the drill pipe 130 to create the Measurement WhileDrilling (MWD) of the Logging While Drilling (LWD) tools. The metal usedto create these tools can be high strength carbon steel for normalranges of downhole HPHT (up to 17,000 psi for pressure and 380° F. fortemperature). For corrosive in-situ operation environments, Nickel basedCorrosive Resistance Alloys (CRA) can be used. The corrosive environmentis characterized by high H₂S or CO₂ content and exposure. For higherranges of pressure, temperature, and corrosion, the integratedcomponents of the 3D imaging tool 160 can be incorporated within otherhigh strength metal tubulars such as Duplex Stainless Steels. Theintegrated rangefinder 162 can employ an active measuring techniquewhere unilateral transmission and passive reflection are used to measurethe dimensions of a point of interest in the wellbore. The transmissionsignal can be a laser beam, short pulse of radio signal (electromagneticradiation), sound propagation, Lidar, other electrical signals, orultrasound signals.

Using the 3D imaging tool 160 to scan and identify problematic areasdownhole can provide one or more advantages. For example, unliketraditional techniques such as corrosion logs or cement bonding logs,which target specific downhole problems with limited applicability, the3D imaging tool 160 can be used to discover a wide range of issues,including for example, casing tears, formation fractures, cementde-bonding, or others. This approach works in cased holes and openholes. Additionally, this approach provides data with high resolutionand reliability. The 3D imaging tool 160 can detect the area ofintegrity failure downhole by locating the depth, shape, and extent offailure with a high level of precision to enable the production of a 3Dreconstruction of such area. Moreover, the 3D imaging tool 160 can beused to produce images and transmit the data to the surface for furtheranalysis without interruption to operations in a drilling process.Examples of operations in the drilling process includes a drillingoperation and a tripping operation (pulling drill pipe out of hole orrunning drill pipe in hole).

In some implementations, as illustrated, the 3D imaging tool 160 can bepart of the in-situ well integrity reconstruction device 190 that isused to discover well integrity issues for reconstruction. In these orother cases, the images and results generated by the 3D imaging tool160, including for example, the images and results generated by therangefinder 162, the radiance sensor 164, and the endoscope 166, can betransmitted to the controller 170 to be used to direct the 3D laser head150 to perform reconstruction operations. Alternatively or additionally,the 3D imaging tool 160 can be implemented as a stand-alone deviceattached to the drill pipe using bottom hole assembly. The 3D imagingtool 160 can perform scanning operations during the drilling process andtransmit images to the surface device 176 in real-time for analysis. Insome cases, clear drilling fluid are present in the tubular when the 3Dimaging tool 160 performs the scanning operations.

Returning to FIG. 1A, the in-situ well integrity reconstruction device190 also includes the laser generator 174. The laser generator 174generates a laser beam that can be used by the 3D laser head 150 forreconstruction operations. In some implementations, the laser generator174 can be implemented as part of the 3D laser head 150. Alternatively,the laser generator 174 can be implemented in a separate unit, forexample, a device that generates laser beam on the surface and directsthe laser beam to the 3D laser head 150 through a fiber optic cable.

The in-situ well integrity reconstruction device 190 also includes the3D laser head 150. The 3D laser head 150 is configured to direct laserbeams generated by the laser generator 174 towards the rock fractures atlocation 122, for reconstruction operations. FIG. 2 and associateddescriptions provide additional details of the operations of the 3Dlaser head 150.

The in-situ well integrity reconstruction device 190 also includes thecontroller 170. The controller 170 can include processors that areconfigured to control the operations of the 3D imaging tool 160, the 3Dlaser head 150, the laser generator 174, or any combinations thereof.The controller 170 can also interact with the surface device 176 totransmit measurement results and receive operation commands. FIG. 3 andassociated descriptions provide additional details of the operations ofthe controller 170. In some cases, as illustrated, one controller 170can be implemented to control multiple components of the in-situ wellintegrity reconstruction device. Alternatively or additionally, each ofthe components, for example, the 3D laser head 150 or the 3D imagingtool 160, can include a controller that controls the operations of therespective component.

The well system 100 also includes the surface device 176. The surfacedevice 176 represents a computing device that is configured to interactwith the in-situ well integrity reconstruction device. For example, thesurface device 176 can receive measurement results from the 3D imagingtool 160 in real time. The measurement results can be outputted andanalyzed by the surface device 176. A problematic area can be identifiedby the surface device 176 based on the measurement results. In somecases, the surface device 176 can instruct the 3D laser head 150 toperform reconstruction operations on the identified problematic area.

The well system 100 also includes a fiber optics cable 172. The fiberoptics cable 172 can connect the in-situ well integrity reconstructiondevice 190 with the surface device 176 or other devices on the surface.The fiber optics cable 172 can be used to provide communications for thein-situ well integrity reconstruction device, or any components of thein-situ well integrity reconstruction device 190 with devices on thesurface of the reservoir. In some implementations, the fiber opticscable 172 can also be used to supply power to the in-situ well integrityreconstruction device. For example, the fiber optics cable 172 canconnect the in-situ well integrity reconstruction device 190 with apower generator operating on the surface. Alternatively or additionally,power for the in-situ well integrity reconstruction device 190 can beprovided by a downhole power supplier such as a rechargeable battery, anenergy harvester, a downhole turbine, or through the integrated powertransmission of the drill pipe 130.

FIG. 1A illustrates an example open hole problem, where rock fracturesare present at location 122, which is in the downhole reservoir rockregion 114 that is beyond the depth of the casing strings 134. Inoperation, the 3D imaging tool 160 scans the location 122 and transmitsthe images to the controller 170, the surface device 176, or both. The3D laser head 150 receives commands from the controller 170, the surfacedevice 176, or both, and directs laser beams towards the location 122 toreconstruct the well. FIGS. 2-9 and associated descriptions provideadditional details of these implementations.

FIG. 1B is a schematic diagram that illustrates an example well systemhaving a cased hole problem, according to an implementation. Asillustrated, the casing string 134 extends to the downhole reservoirrock region 114, and leaks are present at location 124. Similar to theoperations described in FIG. 1A, the 3D imaging tool 160 can scan thelocation 124 and the 3D laser head 150 can direct laser beams towardsthe location 124 to fix the leaks.

FIG. 2 is a block diagram of an example 3D laser head 150 used toperform bottom hole well reconstruction, according to an implementation.At a high level, the 3D laser head 150 includes a cable 210, a protector226, a focused lens 224, and a reflector 222 that are attached to ashaft 230. An 3D laser head may include additional, different, or fewercomponents as shown in FIG. 2, as appropriate.

The cable 210 is an insulated cable that protects the optical fiberinside the cable. The cable 210 is constructed using high temperatureresistant and high pressure resistant materials for downhole operations.For example, the cable 210 can be constructed using off-the-shelfmaterials that protect the fiber optics cable from pressure,temperature, and hydrogen or other invasions from the wellbore orformation The optical fiber can conduct the laser beam 240 towards thereflector 222.

The reflector 222 is configured to reflect the laser beam 240 conductedfrom the optical fiber towards the focused lens 224. In someimplementations, the reflector 222 can be a mirror, a beam splitter, ora prism. The focused lens 224 is configured to focus the laser beam 240reflected by the reflector 222. As illustrated, the focused lens 224 canbe a lens with a short focus so that the laser beam 240 can turn into adivergent beam 242. Both the reflector 222 and the focused lens 224 areconstructed using materials that are suitable for downhole operations.For example, the reflector 222 and the focused lens 224 can beconstructed using coated, high-energy, and high-intensity materials.

The protector 226 is configured to prevent any debris or dust fromblocking the divergent beam 242. The protector 226 can also preventthese debris, including for example, air, gas, fluid, or dust, fromdamaging the focused lens 224. The protector 226 can be a set of knives,guards, or panels.

As illustrated, components such as the cable 210, the protector 226, thefocused lens 224, and the reflector 222 are attached to the shaft 230.In some implementations, these components can be attached to the shaft230 directly. Alternatively or additionally, some of components can beattached to the shaft 230 indirectly. For example, the focused lens 224can be connected to the protector 226, which is in turn connected to theshaft 230. The cable 210 can be attached to the shaft 230 through one ormore rings 236. The reflector 222 can be attached to the shaft 230through an arm 234. The shaft 230 is attached to a tubular such as adrill pipe or a coiled tubular. In some cases, the shaft 230 can beattached to the tubular using one or more connectors 232. The shaft 230can also be attached to the tubular using other components. In someimplementations, instead of using a shaft, other mechanical devices canbe used to connect these different components.

In operation, the laser beam 240 emits from the optical fiber inside thecable 210 towards the reflector 222. The laser beam 240 is reflectedfrom the reflector 222 towards the focused lens 224. The laser beam 240turns into the divergent beam 242 and is directed towards the area ofleaks. The 3D laser head 150 is connected with a controller, for examplethe controller 170 in FIGS. 1A and 1B, and the controller can controlthe movement of 3D laser head 150 to place the reflector 222 and thefocused lens 224 at a location and an angle that can direct thedivergent beam 242 towards the location of the leak to be fixed. Forexample, the arm 234 can be rotated based on the commands received fromthe controller so that the reflector 222 can be rotated towards aspecific angle. The connectors 232 can be released to disconnect theshaft 230 from the tubular when a command is received from thecontroller to move the 3D laser head 150 to a different location on thetubular. The connectors 232 can be re-engaged, and connect the shaft 230with the tubular when the 3D laser head 150 has been moved to thedesignated location. FIG. 3 and associated descriptions provideadditional details of the interactions between the controller and the 3Dlaser head 150. The tubular can be a drill pipe, a coiled tubing, acasing tubular, or other tubulars. The sealing operation can beperformed when the tubular is engaged in a drilling operation, atripping operation, or other operations during a drilling process orhydrocarbon product recovery process.

FIG. 3 is a block diagram of an example in-situ well integrityreconstruction device 300, according to an implementation. At a highlevel, the in-situ well integrity reconstruction device 300 includes the3D laser head 150, the 3D imaging tool 160, and the laser generator 174that are connected to the controller 170. A well integrityreconstruction device may include additional, different, or fewercomponents as shown in FIG. 3, as appropriate.

The controller 170 includes an interface 304, a processor 305, a memory307 and a system bus 203. Although illustrated as a single interface 304in FIG. 3, two or more interfaces 304 may be used according toparticular needs, desires, or particular implementations of thecontroller 170. The interface 204 is used by the controller 170 forcommunicating with other components of the device 300, for example, the3D laser head 150, the 3D imaging tool 160, and the laser generator 174.For example, the interface 204 can receive images transmitted by the 3Dimaging tool 160, transmit commands to the 3D laser head 150 to positionthe 3D laser head 150 at the location corresponding to a leak, andtransmit commands to the laser generator 174 to initiate the laser beam.The interface 204 can also be used by the controller 170 forcommunicating with other devices, for example, the surface device 176.For example, the interface 204 can transmit the images generated by the3D imaging tool 160 to the master device. The interface 204 can receivecommands from the surface device 176 to initiate or stop downhole wellintegrity monitoring or construction operations.

Generally, the interface 304 comprises logic encoded in software orhardware (or a combination of software and hardware). More specifically,the interface 304 may comprise software supporting one or morecommunication protocols associated with communications such that thedevice 300 and is operable to communicate physical signals within andoutside of the illustrated device 300. The interface 304 can beconfigured to support wireline communication protocols, including forexample, coaxial cable, optical cable, twisted pair, or other wirelinecommunication technologies. The interface 304 can also be configured tosupport wireless communication protocols, including for example,microwaves, radiowaves, wireless local area network (WLAN), or otherwireless communication technologies.

The controller 170 includes a processor 305. Although illustrated as asingle processor 305 in FIG. 3, two or more processors may be usedaccording to particular needs, desires, or particular implementations ofthe controller 170. Generally, the processor 305 executes instructionsand manipulates data to perform the operations of the controller 170 andany algorithms, methods, functions, processes, flows, and procedures, asdescribed in the instant disclosure. For example, the processor 305 canbe configured to analyze the images generated by the 3D imaging tool 160to determine whether a leak has been discovered, generate positioningcommands for the 3D laser head 150 to place the 3D laser head 150 at thecorresponding location, generate angling commands for the 3D laser head150 to rotate the reflector and focused lens to the correspondingangles, and control the generation of the laser beam by the lasergenerator 174. The processor 305 can further be configured to analyzethe effects of the laser beam reconstruction based on additional imagesfrom the 3D imaging tool and determine whether to generate additionallaser beam towards the leak.

The controller 170 also includes a memory 307 that can hold data for thecontroller 170. In some cases, the memory 307 can also hold programminginstructions that are executable by the processor 305 to performoperations discussed previously. For example, memory 307 can be randomaccess memory (RAM), read only memory (ROM), optical, magnetic, and thelike, storing data consistent with this disclosure. In someimplementations, memory 307 can be a combination of two or moredifferent types of memory (for example, a combination of RAM andmagnetic storage) according to particular needs, desires, or particularimplementations of the controller 170 and the described functionality.Although illustrated as a single memory 307 in FIG. 3, two or morememories 307 (of the same or a combination of types) can be usedaccording to particular needs, desires, or particular implementations ofthe controller 170 and the described functionality.

Each of the components of the controller 170 can communicate using thesystem bus 303. In some implementations, any or all of the components ofthe controller 170, hardware or software (or a combination of bothhardware and software), may interface with each other or the interface304 (or a combination of both), over the system bus 303, usingstandardized or proprietary protocols.

FIG. 4 illustrates example effects of laser sealing, according to animplementation. FIG. 4 includes a chart 410 that illustrates examplethermal analysis. The chart 410 includes a curve 412 for clay. Asillustrated, clays can collapse under about 200 degrees, spall at about400 degrees, dissociate at about 900 degrees, melt at about 1100degrees, and vaporizes at about 1300 degrees. Pictures 420, 422, 424,426, and 428 show example effects of collapsing, spalling, dissociation,melting, and vaporization, respectively. Other rock types may havedifferent curves. For example, sandstone may melt at about 1400 degrees,and limestone may dissociate at 1100 degrees. In some cases, the type ofrocks around the leaks to be fixed can be determined, and the laser beamcan be configured to deliver the energy required to melt, vaporize ordissociated the rock. For example, the laser beam can be configured tomelt the rocks in a sealing operation. The temperature increase on therock is based on several factors, including rock type and thermalproperties, rock color, laser power, spot size, and time. Therefore,rock temperature under the laser beam can be controlled based on theseparameters.

In some implementations, the types of rocks can be determined based onone or more of the following techniques. In one example, the types ofrocks can be determined based on off-set wells data. If the planned wellis drilled in an area where other wells have been drilled previously,the information from these old and nearby wells (referred to offsetwells) can be used to determine the formations that will be penetratedby the new well and the type of rocks comprising each formation. Inanother example, the types of rocks can be determined based on rockcuttings during the drilling process. During the drilling process of thenew well, rock cuttings produced by the drill bit downhole aretransported to the surface through the circulating drilling fluids andare filtered from the fluids using solids control equipment on thesurface. These rock cuttings are used to characterize the type of rocksdrilled and correlated to a depth interval. In yet another example, thetypes of rocks can be determined based on the trends and behaviors ofthe drill bit and drill string. During the drilling process, trends andbehaviors of the drill bit and the drill string can be detected at thesurface. These trends and behaviors can be used to predict a change ofthe rock type being drilled. For example, sudden changes in the rate ofpenetration (ROP) of the drill bit can be correlated to a change in therock type drilled. In yet another example, the types of rocks can bedetermined based on measurement of MWD or LWD tools operating during thedrilling process. Example measurements performed by these MWD or LWDtools can include gamma ray radiations, quantifying the hydrogen orneutron contents, measuring resistivity, and sonic waves travel times.In some cases, a combination of these techniques can be used todetermine the types of rocks. Based on the types of rocks, differentlaser power, spot size, or time can be configured to obtain the targettemperature to melt the rocks.

In some implementations, the sealing operation can also be directed tomaterials other than the rock formation at point of leaks. For example,the leak can be located at a downhole location on a casing tubular, andthe laser beam can be directed to the portion of the casing tubularwhere the leak occurs.

FIG. 5 illustrates an example laser sealing operation, according to animplementation. As illustrated, location 520 represents the location ofan open hole leak in rock formation 510. Under the laser beam, glass wasformed by the rock to seal the leak and stop loss circulation.

FIG. 6 illustrates another example laser sealing operation, according toan implementation. Photo 610 shows the glass structured of fused silicathat sealed the wellbore, while photo 620 shows the cross section of thesealed wellbore.

FIG. 7 illustrates yet another example laser sealing operation,according to respective implementations. Photo 710 shows loss sandconsolidated by laser beam for sealing, while photo 720 shows a laserbeam that is delivered to the loss sand.

FIG. 8 is a block diagram of an example computer system 800 used toprovide computational functionalities associated with describedalgorithms, methods, functions, processes, flows, and procedures, asdescribed in the instant disclosure, according to an implementation. Thecomputer system 800, or more than one computer system 800, can be usedto implement the surface device that interopreates with the in-situ wellintegrity reconstruction device as described previously. The computersystem 800, or more than one computer system 800, can also be used tosend commands to the in-situ well integrity reconstruction device tocontrol the operations of the in-situ well integrity reconstructiondevice.

The illustrated computer 802 is intended to encompass any computingdevice such as a server, desktop computer, laptop/notebook computer,wireless data port, smart phone, personal data assistant (PDA), tabletcomputing device, one or more processors within these devices, or anyother suitable processing device, including physical or virtualinstances (or both) of the computing device. Additionally, the computer802 may comprise a computer that includes an input device, such as akeypad, keyboard, touch screen, or other device that can accept userinformation, and an output device that conveys information associatedwith the operation of the computer 802, including digital data, visual,or audio information (or a combination of information), or a graphicaluser interface (GUI).

The computer 802 can serve in a role as a client, network component, aserver, a database or other persistency, or any other component (or acombination of roles) of a computer system for performing the subjectmatter described in the instant disclosure. The illustrated computer 802is communicably coupled with a network 830. In some implementations, oneor more components of the computer 802 may be configured to operatewithin environments, including cloud-computing-based, local, global, orother environment (or a combination of environments).

At a high level, the computer 802 is an electronic computing deviceoperable to receive, transmit, process, store, or manage data andinformation associated with the described subject matter. According tosome implementations, the computer 802 may also include, or becommunicably coupled with, an application server, e-mail server, webserver, caching server, streaming data server, or other server (or acombination of servers).

The computer 802 can receive requests over network 830 from a clientapplication (for example, executing on another computer 802) and respondto the received requests by processing the received requests using anappropriate software application(s). In addition, requests may also besent to the computer 802 from internal users (for example, from acommand console or by other appropriate access methods), external orthird-parties, other automated applications, as well as any otherappropriate entities, individuals, systems, or computers.

Each of the components of the computer 802 can communicate using asystem bus 803. In some implementations, any or all of the components ofthe computer 802, hardware or software (or a combination of bothhardware and software), may interface with each other or the interface804 (or a combination of both), over the system bus 803 using anapplication programming interface (API) 812 or a service layer 813 (or acombination of the API 812 and service layer 813). The API 812 mayinclude specifications for routines, data structures, and objectclasses. The API 812 may be either computer-language independent ordependent and may refer to a complete interface, a single function, oreven a set of APIs. The service layer 813 provides software services tothe computer 802 or other components (whether or not illustrated) thatare communicably coupled to the computer 802. The functionality of thecomputer 802 may be accessible for all service consumers using thisservice layer. Software services, such as those provided by the servicelayer 813, provide reusable, defined functionalities through a definedinterface. For example, the interface may be software written in JAVA,C++, or other suitable language providing data in extensible markuplanguage (XML) format or other suitable format. While illustrated as anintegrated component of the computer 802, alternative implementationsmay illustrate the API 812 or the service layer 813 as stand-alonecomponents in relation to other components of the computer 802 or othercomponents (whether or not illustrated) that are communicably coupled tothe computer 802. Moreover, any or all parts of the API 812 or theservice layer 813 may be implemented as child or sub-modules of anothersoftware module, enterprise application, or hardware module withoutdeparting from the scope of this disclosure.

The computer 802 includes an interface 804. Although illustrated as asingle interface 804 in FIG. 8, two or more interfaces 804 may be usedaccording to particular needs, desires, or particular implementations ofthe computer 802. The interface 804 is used by the computer 802 forcommunicating with other systems that are connected to the network 830(whether illustrated or not) in a distributed environment. Generally,the interface 804 comprises logic encoded in software or hardware (or acombination of software and hardware) and is operable to communicatewith the network 830. More specifically, the interface 804 may comprisesoftware supporting one or more communication protocols associated withcommunications such that the network 830 or interface's hardware isoperable to communicate physical signals within and outside of theillustrated computer 802. For example, the interface 804 can be used toreceive 3D images from the in-situ well integrity reconstruction device,transmit operating command to the in-situ well integrity reconstructiondevice, or a combination thereof.

The computer 802 includes a processor 805. Although illustrated as asingle processor 805 in FIG. 8, two or more processors may be usedaccording to particular needs, desires, or particular implementations ofthe computer 802. Generally, the processor 805 executes instructions andmanipulates data to perform the operations of the computer 802 and anyalgorithms, methods, functions, processes, flows, and procedures asdescribed in the instant disclosure.

The computer 802 also includes a database 806 that can hold data for thecomputer 802 or other components (or a combination of both) that can beconnected to the network 830 (whether illustrated or not). The database806 can be an in-memory, conventional, or other type of database storingdata consistent with this disclosure. In some implementations, database806 can be a combination of two or more different database types (forexample, a hybrid in-memory and conventional database) according toparticular needs, desires, or particular implementations of the computer802 and the described functionality. Although illustrated as a singledatabase 806 in FIG. 8, two or more databases (of the same orcombination of types) can be used according to particular needs,desires, or particular implementations of the computer 802 and thedescribed functionality. While database 806 is illustrated as anintegral component of the computer 802, in alternative implementations,database 806 can be external to the computer 802.

The computer 802 also includes a memory 807 that can hold data for thecomputer 802 or other components (or a combination of both) that can beconnected to the network 830 (whether illustrated or not). For example,memory 807 can be random access memory (RAM), read-only memory (ROM),optical, magnetic, and the like, storing data consistent with thisdisclosure. In some implementations, memory 807 can be a combination oftwo or more different types of memory (for example, a combination of RAMand magnetic storage) according to particular needs, desires, orparticular implementations of the computer 802 and the describedfunctionality. Although illustrated as a single memory 807 in FIG. 8,two or more memories 807 (of the same or combination of types) can beused according to particular needs, desires, or particularimplementations of the computer 802 and the described functionality.While memory 807 is illustrated as an integral component of the computer802, in alternative implementations, memory 807 can be external to thecomputer 802.

The application 808 is an algorithmic software engine providingfunctionality according to particular needs, desires, or particularimplementations of the computer 802, particularly with respect tofunctionality described in this disclosure. For example, application 808can serve as one or more components, modules, or applications. Further,although illustrated as a single application 808, the application 808may be implemented as multiple applications 808 on the computer 802. Inaddition, although illustrated as integral to the computer 802, inalternative implementations, the application 808 can be external to thecomputer 802.

The computer 802 can also include a power supply 814. The power supply814 can include a rechargeable or non-rechargeable battery that can beconfigured to be either user- or non-user-replaceable. In someimplementations, the power supply 814 can include power-conversion ormanagement circuits (including recharging, standby, or other powermanagement functionality). In some implementations, the power-supply 814can include a power plug to allow the computer 802 to be plugged into awall socket or other power source to, for example, power the computer802 or recharge a rechargeable battery.

There may be any number of computers 802 associated with, or externalto, a computer system containing computer 802, each computer 802communicating over network 830. Further, the term “client,” “user,” andother appropriate terminology may be used interchangeably, asappropriate, without departing from the scope of this disclosure.Moreover, this disclosure contemplates that many users may use onecomputer 802, or that one user may use multiple computers 802.

Described implementations of the subject matter can include one or morefeatures, alone or in combination.

For example, in a first implementation, a method for downhole wellintegrity reconstruction in a hydrocarbon reservoir includes:positioning, a laser head at a first subterranean location, wherein thelaser head is attached to a tubular inside of a wellbore; directing, bythe laser head, a laser beam towards a leak on the wellbore; and sealingthe leak using the laser beam.

The foregoing and other described implementations can each, optionally,include one or more of the following features:

A first feature, combinable with any of the following features, whereinthe laser head includes a reflector and a focused lens, and wherein themethod further comprises: rotating the reflector and the focused lens toaim at the leak.

A second feature, combinable with any of the previous or followingfeatures, wherein the laser head further includes a protector thatblocks debris for the focused lens.

A third feature, combinable with any of the previous or followingfeatures, wherein the laser head further includes an insulated cablethat protects optical fibers, and wherein the optical fibers conduct thelaser beam.

A fourth feature, combinable with any of the previous or followingfeatures, wherein the leak is sealed while the tubular is engaged in adrilling operation or a tripping operation.

A fifth feature, combinable with any of the previous or followingfeatures, wherein the leak is located in an open hole.

A sixth feature, combinable with any of the previous or followingfeatures, wherein the leak is located in a cased hole.

A seventh feature, combinable with any of the previous or followingfeatures, the method further comprising: receiving a command from acontroller that is communicatively coupled with the laser head, andwherein the laser head is positioned at the first subterranean locationin response to the command.

An eighth feature, combinable with any of the previous or followingfeatures, wherein the first subterranean location is determined based onimages generated by an imaging tool that operates inside the wellbore.

A ninth feature, combinable with any of the previous or followingfeatures, wherein the tubular is a drill pipe.

A tenth feature, combinable with any of the previous features, themethod further comprising: determining a type of rock around the leak;and sealing the leak based on the type of rock.

In a second implementation, an in-situ well integrity reconstructiondevice includes: a 3-dimensional (3D) laser head; at least one hardwareprocessor; and a non-transitory computer-readable storage medium coupledto the at least one hardware processor and storing programminginstructions for execution by the at least one hardware processor,wherein the programming instructions, when executed, cause the in-situwell integrity reconstruction device to perform operations comprising:positioning, the 3D laser head at a first subterranean location, whereinthe 3D laser head is attached to a tubular inside of a wellbore; andwherein the 3D laser head is configured to: direct a laser beam towardsa leak at the first subterranean location; and seal the leak using thelaser beam.

The foregoing and other described implementations can each, optionally,include one or more of the following features:

A first feature, combinable with any of the following features, whereinthe 3D laser head comprises a reflector and a focused lens, and thereflector and the focused lens are configured to be rotated to aim atthe leak.

A second feature, combinable with any of the previous or followingfeatures, wherein the 3D laser head comprises a protector that blocksdebris for the focused lens.

A third feature, combinable with any of the previous or followingfeatures, wherein the 3D laser head comprises an insulated cable thatprotects optical fibers, and wherein the optical fibers conduct thelaser beam.

A fourth feature, combinable with any of the previous or followingfeatures, the in-situ well integrity reconstruction device furthercomprising a 3D scanner configured to generate images inside thewellbore.

A fifth feature, combinable with any of the previous or followingfeatures, wherein the first subterranean location is determined based onthe images generated by the 3D scanner.

A sixth feature, combinable with any of the previous features, whereinthe tubular is a drill pipe.

In a third implementation, an in-situ 3-dimensional (3D) laser headincludes: a reflector that is attached to a tubular inside of awellbore; a focused lens; and wherein the reflector is configured toreflect a laser beam towards the focused lens; and the reflector and thefocused lens are configured to be rotatable to aim towards a leak on thewellbore.

A first feature, combinable with any of the following features, thein-situ 3D laser head further comprising an insulated cable thatprotects optical fibers, and wherein the optical fibers conduct thelaser beam.

In a fourth implementation, an in-situ 3-dimensional (3D) scannerincludes: a rangefinder configured to measure a distance between asubterranean location and a surface of a well; and a radiance sensorconfigured to generate a depth map of the subterranean location.

The foregoing and other described implementations can each, optionally,include one or more of the following features:

A first feature, combinable with any of the following features, thein-situ 3D scanner further comprising an endoscope configured togenerate an image of the subterranean location.

A second feature, combinable with any of the previous or followingfeatures, wherein the endoscope is configured to generate the image byfiltering interferences from measure results of the rangefinder and theradiance sensor.

A third feature, combinable with any of the previous or followingfeatures, the in-situ 3D scanner further comprising an image processorconfigured to process the image generated by the endoscope.

A fourth feature, combinable with any of the previous or followingfeatures, the in-situ 3D scanner further comprising a downhole cameraconfigured to generate an image of the subterranean location.

A fifth feature, combinable with any of the previous or followingfeatures, wherein the rangefinder is integrated with a tubular.

A sixth feature, combinable with any of the previous or followingfeatures, wherein the rangefinder is integrated with the tubular usinghigh strength carbon steel.

A seventh feature, combinable with any of the previous or followingfeatures, wherein the tubular is a drill pipe.

An eighth feature, combinable with any of the previous features, thein-situ 3D scanner further comprising a transmitter configured totransmit measurement results of the rangefinder and the radiance sensorto the surface of the well.

In a fifth implementation, a method for downhole well leak detection ina hydrocarbon reservoir, comprising: positioning, a 3-dimensional (3D)scanner at a subterranean location, wherein the 3D scanner is attachedto a tubular inside of a wellbore; generating an image of thesubterranean location; and transmitting the image to a surface of awell.

The foregoing and other described implementations can each, optionally,include one or more of the following features:

A first feature, combinable with any of the following features, whereinthe 3D scanner comprises a rangefinder configured to measure a distancebetween the subterranean location and the surface of the well.

A second feature, combinable with any of the previous or followingfeatures, wherein the 3D scanner comprises a radiance sensor configuredto generate a depth map of the subterranean location.

A third feature, combinable with any of the previous or followingfeatures, wherein the 3D scanner comprises an endoscope configured togenerate an image of the subterranean location.

A fourth feature, combinable with any of the previous or followingfeatures, wherein the 3D scanner an image processor configured toprocess the image generated by the endoscope.

A fifth feature, combinable with any of the previous or followingfeatures, wherein the 3D scanner comprises a downhole camera configuredto generate the image of the subterranean location.

A sixth feature, combinable with any of the previous or followingfeatures, wherein the rangefinder is integrated with the tubular.

A seventh feature, combinable with any of the previous features, whereinthe tubular is a drill pipe.

In a sixth implementation, a method for downhole well integrityreconstruction in a hydrocarbon reservoir includes: positioning, a3-dimensional (3D) scanner at a subterranean location, wherein the 3Dscanner is attached to a tubular inside of a wellbore; generating animage of the subterranean location; determining, based on the image,that a leak is located at the subterranean location; positioning, alaser head at the subterranean location, wherein the laser head isattached to the tubular; directing, by the laser head, a laser beamtowards the leak; and sealing the leak using the laser beam.

The foregoing and other described implementations can each, optionally,include one or more of the following features:

A first feature, combinable with any of the following features, whereinthe tubular is a drill pipe.

A second feature, combinable with any of the previous features, whereinthe leak is sealed while the tubular is engaged in a drilling operationor a tripping operation.

Implementations of the subject matter and the functional operationsdescribed in this specification can be implemented in digital electroniccircuitry, in tangibly embodied computer software or firmware, incomputer hardware, including the structures disclosed in thisspecification and their structural equivalents, or in combinations ofone or more of them. Implementations of the subject matter described inthis specification can be implemented as one or more computer programs,that is, one or more modules of computer program instructions encoded ona tangible, non-transitory, computer-readable computer-storage mediumfor execution by, or to control the operation of, data processingapparatus. Alternatively, or additionally, the program instructions canbe encoded in/on an artificially generated propagated signal, forexample, a machine-generated electrical, optical, or electromagneticsignal that is generated to encode information for transmission tosuitable receiver apparatus for execution by a data processingapparatus. The computer-storage medium can be a machine-readable storagedevice, a machine-readable storage substrate, a random or serial accessmemory device, or a combination of computer-storage mediums.

The term “real-time,” “real time,” “realtime,” “real (fast) time (RFT),”“near(ly) real-time (NRT),” “quasi real-time,” or similar terms (asunderstood by one of ordinary skill in the art), means that an actionand a response are temporally proximate such that an individualperceives the action and the response occurring substantiallysimultaneously. For example, the time difference for a response todisplay (or for an initiation of a display) of data following theindividual's action to access the data may be less than 1 ms, less than1 sec., or less than 5 secs. While the requested data need not bedisplayed (or initiated for display) instantaneously, it is displayed(or initiated for display) without any intentional delay, taking intoaccount processing limitations of a described computing system and timerequired to, for example, gather, accurately measure, analyze, process,store, or transmit the data.

The terms “data processing apparatus,” “computer,” or “electroniccomputer device” (or equivalent as understood by one of ordinary skillin the art) refer to data processing hardware and encompass all kinds ofapparatus, devices, and machines for processing data, including by wayof example, a programmable processor, a computer, or multiple processorsor computers. The apparatus can also be, or further include, specialpurpose logic circuitry, for example, a central processing unit (CPU),an FPGA (field programmable gate array), or an ASIC(application-specific integrated circuit). In some implementations, thedata processing apparatus or special purpose logic circuitry (or acombination of the data processing apparatus or special purpose logiccircuitry) may be hardware- or software-based (or a combination of bothhardware- and software-based). The apparatus can optionally include codethat creates an execution environment for computer programs, forexample, code that constitutes processor firmware, a protocol stack, adatabase management system, an operating system, or a combination ofexecution environments. The present disclosure contemplates the use ofdata processing apparatuses with or without conventional operatingsystems, for example LINUX, UNIX, WINDOWS, MAC OS, ANDROID, IOS, or anyother suitable conventional operating system.

A computer program, which may also be referred to or described as aprogram, software, a software application, a module, a software module,a script, or code can be written in any form of programming language,including compiled or interpreted languages, or declarative orprocedural languages, and it can be deployed in any form, including as astand-alone program or as a module, component, subroutine, or other unitsuitable for use in a computing environment. A computer program may, butneed not, correspond to a file in a file system. A program can be storedin a portion of a file that holds other programs or data, for example,one or more scripts stored in a markup language document, in a singlefile dedicated to the program in question, or in multiple coordinatedfiles, for example, files that store one or more modules, sub-programs,or portions of code. A computer program can be deployed to be executedon one computer or on multiple computers that are located at one site ordistributed across multiple sites and interconnected by a communicationnetwork. While portions of the programs illustrated in the variousfigures are shown as individual modules that implement the variousfeatures and functionality through various objects, methods, or otherprocesses, the programs may instead include a number of sub-modules,third-party services, components, libraries, and such, as appropriate.Conversely, the features and functionality of various components can becombined into single components, as appropriate. Thresholds used to makecomputational determinations can be statically, dynamically, or bothstatically and dynamically determined.

The methods, processes, or logic flows described in this specificationcan be performed by one or more programmable computers executing one ormore computer programs to perform functions by operating on input dataand generating output. The methods, processes, or logic flows can alsobe performed by, and apparatus can also be implemented as, specialpurpose logic circuitry, for example, a CPU, an FPGA, or an ASIC.

Computers suitable for the execution of a computer program can be basedon general or special purpose microprocessors, both, or any other kindof CPU. Generally, a CPU will receive instructions and data from aread-only memory (ROM) or a random access memory (RAM), or both. Theessential elements of a computer are a CPU, for performing or executinginstructions, and one or more memory devices for storing instructionsand data. Generally, a computer will also include, or be operativelycoupled to, receive data from or transfer data to, or both, one or moremass storage devices for storing data, for example, magnetic,magneto-optical disks, or optical disks. However, a computer need nothave such devices. Moreover, a computer can be embedded in anotherdevice, for example, a mobile telephone, a personal digital assistant(PDA), a mobile audio or video player, a game console, a globalpositioning system (GPS) receiver, or a portable storage device, forexample, a universal serial bus (USB) flash drive, to name just a few.

Computer-readable media (transitory or non-transitory, as appropriate)suitable for storing computer program instructions and data includes allforms of non-volatile memory, media and memory devices, including by wayof example semiconductor memory devices, for example, erasableprogrammable read-only memory (EPROM), electrically erasableprogrammable read-only memory (EEPROM), and flash memory devices;magnetic disks, for example, internal hard disks or removable disks;magneto-optical disks; and CD-ROM, DVD+/−R, DVD-RAM, and DVD-ROM disks.The memory may store various objects or data, including caches, classes,frameworks, applications, backup data, jobs, web pages, web pagetemplates, database tables, repositories storing dynamic information,and any other appropriate information including any parameters,variables, algorithms, instructions, rules, constraints, or referencesthereto. Additionally, the memory may include any other appropriatedata, such as logs, policies, security or access data, reporting files,as well as others. The processor and the memory can be supplemented by,or incorporated in, special purpose logic circuitry.

To provide for interaction with a user, implementations of the subjectmatter described in this specification can be implemented on a computerhaving a display device, for example, a CRT (cathode ray tube), LCD(liquid crystal display), LED (Light Emitting Diode), or plasma monitor,for displaying information to the user and a keyboard and a pointingdevice, for example, a mouse, trackball, or trackpad by which the usercan provide input to the computer. Input may also be provided to thecomputer using a touchscreen, such as a tablet computer surface withpressure sensitivity, a multi-touch screen using capacitive or electricsensing, or other type of touchscreen. Other kinds of devices can beused to provide for interaction with a user as well; for example,feedback provided to the user can be any form of sensory feedback, forexample, visual feedback, auditory feedback, or tactile feedback; andinput from the user can be received in any form, including acoustic,speech, or tactile input. In addition, a computer can interact with auser by sending documents to and receiving documents from a device thatis used by the user; for example, by sending web pages to a web browseron a user's client device in response to requests received from the webbrowser.

The term “graphical user interface,” or “GUI,” may be used in thesingular or the plural to describe one or more graphical user interfacesand each of the displays of a particular graphical user interface.Therefore, a GUI may represent any graphical user interface, includingbut not limited to, a web browser, a touch screen, or a command lineinterface (CLI) that processes information and efficiently presents theinformation results to the user. In general, a GUI may include aplurality of user interface (UI) elements, some or all associated with aweb browser, such as interactive fields, pull-down lists, and buttons.These and other UI elements may be related to or represent the functionsof the web browser.

Implementations of the subject matter described in this specificationcan be implemented in a computing system that includes a back-endcomponent, for example, as a data server, or that includes a middlewarecomponent, for example, an application server, or that includes afront-end component, for example, a client computer having a graphicaluser interface or a Web browser through which a user can interact withan implementation of the subject matter described in this specification,or any combination of one or more such back-end, middleware, orfront-end components. The components of the system can be interconnectedby any form or medium of wireline or wireless digital data communication(or a combination of data communication), for example, a communicationnetwork. Examples of communication networks include a local area network(LAN), a radio access network (RAN), a metropolitan area network (MAN),a wide area network (WAN), Worldwide Interoperability for MicrowaveAccess (WIMAX), a wireless local area network (WLAN) using, for example,802.11 a/b/g/n or 802.20 (or a combination of 802.11x and 802.20 orother protocols consistent with this disclosure), all or a portion ofthe Internet, or any other communication system or systems at one ormore locations (or a combination of communication networks). The networkmay communicate with, for example, Internet Protocol (IP) packets, FrameRelay frames, Asynchronous Transfer Mode (ATM) cells, voice, video,data, or other suitable information (or a combination of communicationtypes) between network addresses.

The computing system can include clients and servers. A client andserver are generally remote from each other and typically interactthrough a communication network. The relationship of client and serverarises by virtue of computer programs running on the respectivecomputers and having a client-server relationship to each other.

While this specification contains many specific implementation details,these should not be construed as limitations on the scope of anyinvention or on the scope of what may be claimed, but rather asdescriptions of features that may be specific to particularimplementations of particular inventions. Certain features that aredescribed in this specification in the context of separateimplementations can also be implemented, in combination, in a singleimplementation. Conversely, various features that are described in thecontext of a single implementation can also be implemented in multipleimplementations, separately, or in any suitable sub-combination.Moreover, although previously described features may be described asacting in certain combinations and even initially claimed as such, oneor more features from a claimed combination can, in some cases, beexcised from the combination, and the claimed combination may bedirected to a sub-combination or variation of a sub-combination.

Particular implementations of the subject matter have been described.Other implementations, alterations, and permutations of the describedimplementations are within the scope of the following claims as will beapparent to those skilled in the art. While operations are depicted inthe drawings or claims in a particular order, this should not beunderstood as requiring that such operations be performed in theparticular order shown or in sequential order, or that all illustratedoperations be performed (some operations may be considered optional), toachieve desirable results. In certain circumstances, multitasking orparallel processing (or a combination of multitasking and parallelprocessing) may be advantageous and performed as deemed appropriate.

Moreover, the separation or integration of various system modules andcomponents in the previously described implementations should not beunderstood as requiring such separation or integration in allimplementations, and it should be understood that the described programcomponents and systems can generally be integrated together in a singlesoftware product or packaged into multiple software products.

Accordingly, the previously described example implementations do notdefine or constrain this disclosure. Other changes, substitutions, andalterations are also possible without departing from the spirit andscope of this disclosure.

Furthermore, any claimed implementation is considered to be applicableto at least a computer-implemented method; a non-transitory,computer-readable medium storing computer-readable instructions toperform the computer-implemented method; and a computer systemcomprising a computer memory interoperably coupled with a hardwareprocessor configured to perform the computer-implemented method or theinstructions stored on the non-transitory, computer-readable medium.

What is claimed is:
 1. An in-situ 3-dimensional (3D) scanner,comprising: a rangefinder configured to measure a distance between asubterranean location and a surface of a well; and a radiance sensorconfigured to generate a depth map of the subterranean location.
 2. Thein-situ 3D scanner of claim 1, further comprising an endoscopeconfigured to generate an image of the subterranean location.
 3. Thein-situ 3D scanner of claim 2, wherein the endoscope is configured togenerate the image by filtering interferences from measure results ofthe rangefinder and the radiance sensor.
 4. The in-situ 3D scanner ofclaim 1, further comprising an image processor configured to process theimage generated by the endoscope.
 5. The in-situ 3D scanner of claim 1,further comprising: a downhole camera configured to generate an image ofthe subterranean location.
 6. The in-situ 3D scanner of claim 1, whereinthe rangefinder is integrated with a tubular.
 7. The in-situ 3D scannerof claim 6, wherein the rangefinder is integrated with the tubular usinghigh strength carbon steel.
 8. The in-situ 3D scanner of claim 6,wherein the tubular is a drill pipe.
 9. The in-situ 3D scanner of claim1, further comprising: a transmitter configured to transmit measurementresults of the rangefinder and the radiance sensor to the surface of thewell.
 10. A method for downhole well leak detection in a hydrocarbonreservoir, comprising: positioning, a 3-dimensional (3D) scanner at asubterranean location, wherein the 3D scanner is attached to a tubularinside of a wellbore; generating an image of the subterranean location;and transmitting the image to a surface of a well.
 11. The method ofclaim 10, wherein the 3D scanner comprises a rangefinder configured tomeasure a distance between the subterranean location and the surface ofthe well.
 12. The method of claim 10, wherein the 3D scanner comprises aradiance sensor configured to generate a depth map of the subterraneanlocation.
 13. The method of claim 10, wherein the 3D scanner comprisesan endoscope configured to generate an image of the subterraneanlocation.
 14. The method of claim 10, wherein the 3D scanner an imageprocessor configured to process the image generated by the endoscope.15. The method of claim 10, wherein the 3D scanner comprises a downholecamera configured to generate the image of the subterranean location.16. The method of claim 10, wherein the rangefinder is integrated withthe tubular.
 17. The method of claim 10, wherein the tubular is a drillpipe.
 18. A method for downhole well integrity reconstruction in ahydrocarbon reservoir, comprising: positioning, a 3-dimensional (3D)scanner at a subterranean location, wherein the 3D scanner is attachedto a tubular inside of a wellbore; generating an image of thesubterranean location; determining, based on the image, that a leak islocated at the subterranean location; positioning, a laser head at thesubterranean location, wherein the laser head is attached to thetubular; directing, by the laser head, a laser beam towards the leak;and sealing the leak using the laser beam.
 19. The method of claim 18,wherein the tubular is a drill pipe.
 20. The method of claim 18, whereinthe leak is sealed while the tubular is engaged in a drilling operationor a tripping operation.